CN113866827A - Method, system, medium and device for explanatory velocity modeling seismic imaging - Google Patents

Method, system, medium and device for explanatory velocity modeling seismic imaging Download PDF

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CN113866827A
CN113866827A CN202111149794.4A CN202111149794A CN113866827A CN 113866827 A CN113866827 A CN 113866827A CN 202111149794 A CN202111149794 A CN 202111149794A CN 113866827 A CN113866827 A CN 113866827A
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imaging
velocity
seismic
explanatory
imaging result
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CN113866827B (en
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王志伟
符力耘
简世凯
邓武兵
李卿卿
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China University of Petroleum East China
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. analysis, for interpretation, for correction
    • G01V1/30—Analysis
    • G01V1/303—Analysis for determining velocity profiles or travel times
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. analysis, for interpretation, for correction
    • G01V1/30—Analysis
    • G01V1/301—Analysis for determining seismic cross-sections or geostructures
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. analysis, for interpretation, for correction
    • G01V1/282—Application of seismic models, synthetic seismograms
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. analysis, for interpretation, for correction
    • G01V1/30—Analysis
    • G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. analysis, for interpretation, for correction
    • G01V1/34—Displaying seismic recordings or visualisation of seismic data or attributes
    • G01V1/345—Visualisation of seismic data or attributes, e.g. in 3D cubes
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/50—Corrections or adjustments related to wave propagation
    • G01V2210/51—Migration
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/61—Analysis by combining or comparing a seismic data set with other data
    • G01V2210/614—Synthetically generated data
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/62—Physical property of subsurface
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/62—Physical property of subsurface
    • G01V2210/622—Velocity, density or impedance
    • G01V2210/6222—Velocity; travel time
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/67—Wave propagation modeling
    • G01V2210/679—Reverse-time modeling or coalescence modelling, i.e. starting from receivers
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/70—Other details related to processing
    • G01V2210/74—Visualisation of seismic data

Abstract

The invention belongs to the technical field of seismic exploration imaging, and relates to an explanatory velocity modeling seismic imaging method, a system, a medium and equipment, which comprise the following steps: s1, carrying out first imaging on the given initial velocity model to obtain a first imaging result; s2, performing relative wave impedance inversion on the first imaging result to obtain a relative wave impedance profile; s3 Cruvelet filtering is carried out on the relative impedance profile to obtain a first explanation scheme; s4, superposing the first interpretation scheme and the initial velocity model to obtain a new offset velocity field; s5, carrying out secondary imaging on the new offset velocity field to obtain a secondary imaging result; s6 repeating the steps S2-S4 for the obtained second imaging result until the final seismic imaging result is obtained. The imaging section contains more construction details, so that the seismic interpreter obtains richer geological features on the imaging section.

Description

Method, system, medium and device for explanatory velocity modeling seismic imaging
Technical Field
The invention relates to an explanatory velocity modeling seismic imaging method, system, medium and equipment, belonging to the technical field of seismic exploration, in particular to the technical field of seismic exploration imaging.
Background
Velocity modeling, seismic migration, and seismic inversion are three conventional areas of exploration seismology. The conventional velocity modeling comprises migration velocity analysis such as dynamic correction stacking, prestack time, time-depth conversion, prestack depth and the like, and the conventional velocity modeling only uses travel time information, so that the average effect is strong, and the established velocity field is very smooth and is not suitable for migration imaging of high-frequency seismic data. With the most advanced least squares reverse time depth migration at present, the imaging profile obtained based on such smooth velocity field seismic migration contains less structural detail.
Disclosure of Invention
In view of the above problems, an object of the present invention is to provide an explanatory velocity modeling seismic imaging method, system, medium, and device, which develop geologic structure explanatory velocity modeling by high-precision migration imaging and subsequent data processing of a prominent structure from an initial velocity model, and then perform migration imaging, so that an imaging section contains more construction details, thereby enabling seismic interpreters to obtain richer geological features on the imaging section.
In order to achieve the purpose, the invention adopts the following technical scheme: an explanatory velocity modeling seismic imaging method, comprising: s1, carrying out first imaging on the given initial velocity model to obtain a first imaging result; s2, performing relative wave impedance inversion on the first imaging result to obtain a relative wave impedance profile; s3 Cruvelet filtering is carried out on the relative impedance profile to obtain a first explanation scheme; s4, superposing the first interpretation scheme and the initial velocity model to obtain a new offset velocity field; s5, carrying out secondary imaging on the new offset velocity field to obtain a secondary imaging result; s6 repeating the steps S2-S4 for the obtained second imaging result until the final seismic imaging result is obtained.
Further, the first and second imaging are obtained by inputting a given initial velocity model or a new offset velocity field into a least squares reverse time offset algorithm.
Further, the relative wave impedance inversion is directly inverted based on the deconvolution method.
Further, the method for inverting the relative wave impedance is to calculate the relative wave impedance on a relative wave impedance profile, obtain a standard impedance by offset velocity analysis, and perform normalization calibration on the standard impedance to obtain the relative velocity profile.
Further, the similarity of the imaging result obtained each time and the imaging result of the real solution breaking model is calculated, so that the imaging result of each explanatory velocity modeling is verified.
Further, the given initial velocity model is obtained through conventional velocity modeling, the sizes of transverse grids and longitudinal grids of the initial velocity model and the number of the grids are given, and shot gather records based on the initial velocity model are obtained through a finite difference method.
Further, the initial velocity model includes the following model parameters: the method comprises the following steps of transverse and longitudinal grid size, transverse and longitudinal grid spacing, wavelet time length and dominant frequency, time sampling interval, total time length, the number of seismic sources, spacing between the seismic sources and the initial position of the transverse and longitudinal coordinates of the seismic sources.
The invention also includes an explanatory velocity modeling seismic imaging system, comprising: the primary imaging module is used for carrying out primary imaging on the given initial speed model to obtain a primary imaging result; the relative wave impedance inversion module is used for carrying out relative wave impedance inversion on the first imaging result to obtain a relative wave impedance profile; the interpretation module is used for Cruvelet filtering on the relative impedance profile to obtain a first interpretation scheme; the superposition module is used for superposing the first interpretation scheme and the initial velocity model so as to obtain a new offset velocity field; the second imaging module is used for carrying out second imaging on the new offset velocity field to obtain a second imaging result; and the circulation module is used for inputting the obtained secondary imaging result into the relative wave impedance inversion module and the interpretation module for circulation until a final seismic imaging result is obtained.
The invention also includes a computer readable storage medium storing one or more programs, the one or more programs comprising instructions, which when executed by a computing device, cause the computing device to perform the method of explanatory velocity modeling seismic imaging according to any of the above.
The invention also includes a computing device comprising: one or more processors, memory, and one or more programs, wherein the one or more programs are stored in the memory and configured to be executed by the one or more processors, the one or more programs including instructions for performing the method for explanatory velocity modeling seismic imaging according to any of the above.
Due to the adoption of the technical scheme, the invention has the following advantages:
1. according to the invention, the velocity model is updated to perform imaging, the obtained result is closer to the seismic imaging result of the real velocity model, the detail structure which is not shown by the first round of imaging section is added, the structure is more convergent, the follow-up seismic interpretation work is effectively guided, and the method has important significance for oil and gas exploration and development.
2. Velocity modeling, seismic migration, and seismic inversion are three traditional areas of exploration seismology. In general, velocity modeling has a direct relationship with seismic migration, and velocity modeling provides an initial velocity field for seismic migration; the velocity modeling and the seismic inversion have a direct relation, the velocity modeling provides low-frequency information for the seismic inversion, in practical application, the seismic migration and the seismic inversion are not directly connected, and the connection between the seismic migration and the seismic inversion is established. The invention can be widely applied to the field of seismic migration imaging.
Drawings
FIG. 1 is a flow chart of a seismic imaging method for explanatory velocity modeling in one embodiment of the invention;
FIG. 2 is a model of true solution break velocity in an embodiment of the present invention;
FIG. 3 is a least squares reverse time migration imaging profile of a true solution velocity model in an embodiment of the present invention;
FIG. 4 is a plot of the offset velocity field of a true solution velocity model in an embodiment of the present invention;
FIG. 5 is a graph of the results of a first imaging of the offset velocity field of a true solution velocity model in an embodiment of the present invention;
FIG. 6 is a relative wave impedance profile of a plot of the results of a first imaging of a true solution velocity model in an embodiment of the present invention;
FIG. 7 is a diagram of an explanation of a true solution velocity model based on a relative wave impedance profile according to an embodiment of the present invention;
FIG. 8 is an image of an updated offset velocity field, which is the result of superposition of an interpretation scheme and the offset velocity field in one embodiment of the invention;
fig. 9 is a diagram showing the result of the second imaging in the embodiment of the present invention.
Detailed Description
The present invention is described in detail by way of specific embodiments in order to better understand the technical direction of the present invention for those skilled in the art. It should be understood, however, that the detailed description is provided for a better understanding of the invention only and that they should not be taken as limiting the invention. In describing the present invention, it is to be understood that the terminology used is for the purpose of description only and is not intended to be indicative or implied of relative importance.
Example one
The embodiment discloses an explanatory velocity modeling seismic imaging method, as shown in fig. 1, including:
the present embodiment is described by taking a solution velocity model as an example, and a real model image of the solution velocity model is shown in fig. 2. Synthetic seismic shot gather data is generated based on the solution velocity model, and a true velocity model Migration imaging section shown in fig. 3 is obtained by using least square Reverse Time Migration imaging (RTM — Reverse Time Migration).
S1 performs a first imaging of the given initial velocity model to obtain a first imaging result.
An initial velocity model is given, as shown in fig. 4, which is obtained by conventional velocity modeling, and the transverse and longitudinal grid sizes and the grid number of the initial velocity model are given, and shot gather records based on the initial velocity model are obtained by a finite difference method.
The initial velocity model includes the following model parameters: the method comprises the following steps of transverse and longitudinal grid size, transverse and longitudinal grid spacing, wavelet time length and dominant frequency, time sampling interval, total time length, the number of seismic sources, spacing between the seismic sources and the initial position of the transverse and longitudinal coordinates of the seismic sources.
S2, relative wave impedance inversion is carried out on the first imaging result to obtain a relative wave impedance profile.
The first imaging result is obtained by imaging the initial velocity model based on the parameters of the offset velocity model and shot gather data by using a least square reverse time offset method, and in this embodiment, the first imaging result is shown in fig. 5, in which the model parameters are the same as those of the initial velocity model
The relative wave impedance inversion is directly inverted based on a deconvolution method, and the method has the characteristics of simple calculation and no restriction by geological data and well data. Specifically, the relative wave impedance is calculated on a relative wave impedance profile, a standard impedance is obtained by offset velocity analysis, and a relative velocity profile is obtained by performing normalization calibration on the standard impedance, which is specifically shown in fig. 6.
S3 Cruvelet filtering is carried out on the relative impedance profile to highlight the geological structure, and a first explanation scheme is obtained, and the result is shown in figure 7.
S4 superimposes the first interpretation with the initial velocity model to obtain a new offset velocity field, as shown in fig. 8.
S5 performs a second imaging of the new offset velocity field to obtain a second imaging result, as shown in fig. 9.
And the second imaging result is based on the parameters of the offset velocity model and shot gather data, and a least square reverse time offset method is adopted to image a new offset velocity field to obtain the new offset velocity field.
S6 repeating the steps S2-S4 for the obtained second imaging result until the final seismic imaging result is obtained. By such iteration, the seismic imaging profile gradually approximates the true geological structure.
And respectively carrying out similarity calculation on the imaging result obtained each time and the imaging result of the real solution breaking model so as to verify the imaging result of each explanatory velocity modeling and judge the effectiveness of the method. And respectively carrying out similarity calculation on the first imaging result and the second imaging result and the imaging result of a real solution model (namely, a real velocity imaging section obtained based on the image in the figure 2, namely, the figure 3), wherein the larger the similarity is, the better the effect of the explanatory velocity modeling seismic imaging method is. The first round imaging profile had a similarity of 71.46% to the true velocity imaging profile and the second round imaging profile had a similarity of 81.28% to the true velocity imaging profile. After two iterations, the imaging effect is improved by nearly 10%.
Example two
Based on the same inventive concept, the present embodiments include an explanatory velocity modeling seismic imaging system, comprising:
the primary imaging module is used for carrying out primary imaging on the given initial speed model to obtain a primary imaging result;
the relative wave impedance inversion module is used for carrying out relative wave impedance inversion on the first imaging result to obtain a relative wave impedance profile;
the interpretation module is used for Cruvelet filtering on the relative impedance profile to obtain a first interpretation scheme;
the superposition module is used for superposing the first interpretation scheme and the initial velocity model so as to obtain a new offset velocity field;
the second imaging module is used for carrying out second imaging on the new offset velocity field to obtain a second imaging result;
and the circulation module is used for inputting the obtained secondary imaging result into the relative wave impedance inversion module and the interpretation module for circulation until a final seismic imaging result is obtained.
EXAMPLE III
Based on the same inventive concept, the present embodiments include a computer readable storage medium storing one or more programs, the one or more programs comprising instructions, which when executed by a computing device, cause the computing device to perform the method of explanatory velocity modeling seismic imaging according to any of the above.
Example four
Based on the same inventive concept, the present embodiments include a computing device comprising: one or more processors, memory, and one or more programs, wherein the one or more programs are stored in the memory and configured to be executed by the one or more processors, the one or more programs including instructions for performing the method for explanatory velocity modeling seismic imaging according to any of the above.
As will be appreciated by one skilled in the art, embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solutions of the present invention and not for limiting the same, and although the present invention is described in detail with reference to the above embodiments, those of ordinary skill in the art should understand that: modifications and equivalents may be made to the embodiments of the invention without departing from the spirit and scope of the invention, which is to be covered by the claims. The above description is only for the specific embodiments of the present application, but the scope of the present application is not limited thereto, and any person skilled in the art can easily conceive of the changes or substitutions within the technical scope of the present application, and shall be covered by the scope of the present application. Therefore, the protection scope of the present application should be defined by the claims.

Claims (10)

1. A method of explanatory velocity modeling seismic imaging, comprising:
carrying out first imaging on the given initial speed model to obtain a first imaging result;
performing relative wave impedance inversion on the first imaging result to obtain a relative wave impedance profile;
cruvelet filtering is carried out on the relative impedance profile to obtain a first interpretation scheme;
superposing the first interpretation scheme and the initial velocity model to obtain a new offset velocity field;
carrying out secondary imaging on the new offset velocity field to obtain a secondary imaging result;
and repeating the steps of the relative wave impedance inversion and Cruvelet filtering on the obtained second imaging result until a final seismic imaging result is obtained.
2. A method of explanatory velocity modeling seismic imaging as claimed in claim 1, wherein said first and second imaging are obtained by inputting a given initial velocity model or a new migration velocity field into a least squares reverse time migration algorithm.
3. The method of explanatory velocity modeling seismic imaging as claimed in claim 1, wherein said relative wave impedance inversion is directly inverted based on deconvolution.
4. The method of explanatory velocity modeling seismic imaging as claimed in claim 3, characterized in that said method of relative wave impedance inversion is to calculate the relative wave impedance on the relative wave impedance profile, to obtain the standard impedance by migration velocity analysis, to perform a normalized calibration of said standard impedance to obtain the relative velocity profile.
5. The method of claim 1, wherein the similarity between each acquired imaging result and the imaging result of the true solution model is calculated to verify the imaging result of each explanatory velocity model.
6. The method of explanatory velocity modeling seismic imaging as claimed in claim 1, wherein the given initial velocity model is obtained by conventional velocity modeling, and the transverse and longitudinal grid sizes and the grid number of the initial velocity model are given, and shot gather records based on the initial velocity model are obtained by a finite difference method.
7. A method of explanatory velocity modeling seismic imaging as claimed in claim 6, wherein said initial velocity model includes the following model parameters: the method comprises the following steps of transverse and longitudinal grid size, transverse and longitudinal grid spacing, wavelet time length and dominant frequency, time sampling interval, total time length, the number of seismic sources, spacing between the seismic sources and the initial position of the transverse and longitudinal coordinates of the seismic sources.
8. An explanatory velocity modeling seismic imaging system, comprising:
the primary imaging module is used for carrying out primary imaging on the given initial speed model to obtain a primary imaging result;
the relative wave impedance inversion module is used for carrying out relative wave impedance inversion on the first imaging result to obtain a relative wave impedance profile;
the interpretation module is used for Cruvelet filtering on the relative impedance profile to obtain a first interpretation scheme;
the superposition module is used for superposing the first interpretation scheme and the initial velocity model so as to obtain a new offset velocity field;
the second imaging module is used for carrying out second imaging on the new offset velocity field to obtain a second imaging result;
and the circulation module is used for inputting the obtained secondary imaging result into the relative wave impedance inversion module and the interpretation module for circulation until a final seismic imaging result is obtained.
9. A computer readable storage medium storing one or more programs, the one or more programs comprising instructions, which when executed by a computing device, cause the computing device to perform the method of explanatory velocity modeling seismic imaging as claimed in any of claims 1 to 7.
10. A computing device, comprising: one or more processors, memory, and one or more programs stored in the memory and configured to be executed by the one or more processors, the one or more programs including instructions for performing the method of interpretive velocity modeling seismic imaging according to any of claims 1-7.
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